Well testing tool



Oct. 8, 1940. A. BoYNToN WELL TESTING TOOL Filed oct. 4, ,.1938

3 sheets-sheet J.

` 0a, 8,1940. `A. 4BoYNToN f 2,217,043

' WELL TESTING rooL l Filed oct. 4. 1938 s sheets-sheet 2` 1:13:13. "169ALEXANDER' H0 Y/V'ON, 89 /wI/E/VOR,

92o BYLLLL( 92 ATTORNEYS.

oct s, 1940;

A. BOYNTON WELL TESTING TOOL Filed 0G12. 4. 1938 s sheets-sheet 3 Fig:24.

T A WORN/Sys,

Patented oet. s, i940 UNITED STATE-'s PATENT or-Flclaj wam. 'rns'rmoToor. Alexander Boynton, San Antonio, Tex.

Application october 4, 193s, serial N. 233,237 mm. (cl. 16e-1) Myinvention relates to well testing tool or device in which av packercarried by the drill stem or other pipe is lowered to the top of, orslightly above the formation to be tested. The drill pipe is suspendedand supports the packer construction at any desired level. Mechanism isprovided to keep the well uid from entering the drill stem until thepacker has" been expanded against the adjacent formation, so as toprevent downward movement of well iluid from above the packer during thetest. The packer is so expanded by iluid pressure from a piston, thepiston being actuated by a cable. The movement of the piston whichexpands the packer by fluid pressure also opens -the drill stern belowthe packer for entrance of Well uid. This operation, in eiect, pumps thewell dry downr to the level oi the packer. Whatever iluid the wellproduces into the testing tool whilethe packer is set, is a fair test ofwhat the formation below the packer will produce if casing be set' andthe well completed. Releasing the cable pull automatically releases thepacker and closes the liquid intake into the testing tool below thepacker, after which the drill stem may be bailed, swabbed, or with--drawn from the well in order to ascertain the result of the test.

No shoulder, or so-called rat hole, is required as an abutment to setthis packer. It may be set anywhere in the well bore. Neither is itnecessary ,that the drill stem extend to bottom of the well in expandingthe packer. The position of the packer in the well is determined by thelength oil` drill stem above the packer, and not by the length of anchorstring below the packer, the latter string being now generally employedto determine the position of all straight hole packers.

The packer herein employed will not `stick or freeze in the well bore,as packers now used so frequently do; because when the cable pull whichcauses the packer expansion is released,

the pressure of well liquid automatically compresses the packer.

A latch is employed to normally hold the de" the drill lstem or deviceencountering heavy mud,

savings, or other'obstruction which might endanger withdrawal of thetool "unless the drill stem be rotated or pumped through as it islowered.

The drill stem may be pumped through at any time, as well as rotated,while the device is being run into or being withdrawn vfrom the well.v

Some type of bit, usually a ilsh tail, is ordinarily, but notnecessarily, attached to the lower end of the device to facilitatemixing the mud if necessary to do so by rotating the drill stem orpumping through it, either or both, while lowering the device into thewell. r

No turning oi the drill pipe is required to cause expansion of thepacker, or opening or closing of the intake ports; such operation1 beingwholly controlled by means of an lattachable and, detachable cable,operated through tle drill stem from the surface. f

A clutch is provided proximately above the! packer. This clutch isnormally engaged, so that the entire drill stem and device may berotated as a unit. The clutch is adapted tobecome disengaged by the samecable pull which springs the latch and expands the packer. After thepacker has been expanded, `the drill stem from the clutch upward may berotated as in drilling, while the packer and all parts upon which it ismounted remain stationary during the test.

A are or telltale iiuid `is discharged immediately above the packer asthe packer expands to sealing-oil engagement with the -well bore. Thisilare uid is of a different color from that of the well liquid. The areuid remains trapped in the well bore above the/'packer unless the packer`should fail to eiect a complete sealoff. If thepacker, due to someenlargement or otherimperfection in the well bore, should fail to eect acomplete seal-oil, ilare uid will be found with the test fiuid in thedrill stem.

The device also provides for the employment etc., obtaining in the well.

The main objects of this invention are to provide a tormationrtestingdevice for drilled wells, which device has the following advantages: f

First: That it may be safely run into, and readily withdrawn from a'wellfor the purpose of recovering a measured sample ofthe well's productionfrom the horizon below where the packer is set, whether the well becased or uncased; and which device may be also used to discover, locate,and measure leaks through the casing.

Second: That `it operates in a straight bore, and does not require thatan oiset or shoulder be provided by drilling a rat Vhole of reduceddiameter into or through the formation to betested.

Third: That the pipe upon which the device is run may be rotated fromtop to bottom, including the device itself, while it Yis being loweredinto,"or being withdrawn from the well, and which may be pumped throughduring any or all such time.

Fourth: That the pipe may be rotated above the device when a productiontest is being made, while the device and anchor string remainstationary.

Fifth: That affords means -for advising the operator when mud or cavingsthat should be rotated through or pumped out have been encountered, asthe device is being lowered into operating position. v n

Sixth: That, by the action of a piston having suitable effective area,the packer may be set with more force than other packers which employthe weight of drill pipe to expand them.

Seventh: That, by whlly withdrawing the internal pres'sure employed toexpandthe packer, the packer is released and contracted by externalpressure of the well fluid, which pressure also causes the intake portsto close and urges all other parts toward their normal position.

Eighth: That the device may be placed anywhere in a well bore by merelyraising or lowering the drill stem upon which it is run; and that byswabbing or hailing the'test fluid out of the drill stem after eachtest, additional tests may be made in rapid succession by merely raisingor lowering the drill pipe, so as to place the packer in proper positionfor each test.

Ninth: That will show whether any of the fluid recovered in the testcame from a formation other than that being tested.

Tenth: That pressure and temperature recording instruments, and otherinstruments if desired, may be placed in the device for the purpose ofascertaining the pressure and temperature and variations thereof,obtaining during the test in the formation tested.

Eleventh: That, due to the test, or series of tests, which may berapidly conducted at moderate cost with this device, all informationabout a wells production is quickly available, thereby rendering itunnecessary to take cores of the formation in drilling for oil gas,water, or other mineral.

With the foregoing and other related objects in view, reference is nowmade to the drawings, in which Fig. 1 is a side elevation of thepreferredform of the invention shown in a well bore, with portions ofthe device broken out, the expanded position of the packer beingillustrated by dotted.-

lines.

Fig. 2 is a longitudinal section of the upper portion of the deviceindicated in Fig. 1.

Fig. 3 is a longitudinal section of the lower portion, completing thedevice partially shown 'in Fig. 2.

Fig. 4 is a transverse section on the line 4 4,-

Fig. 9 is a transverse section on the line 9-9.

Figs. 3-11.

Fig. 10 is a longitudinal section of the upper portionv of the firstmodified form of the in' vention. J

' Fig. 11 is a longitudinal section of the remaining portion of thedevice not shown-in Fig. 10.

Fig. 12 is a transverse section on the lin Fig. 13 is a transversesection on the lineA Fig'. 15 is a transverse section on the line |5-|6,Fig. 14...l

Fig. 16 is la transverse section on the line 'IB-I6, Fig. 14. p

Fig. 17 is a transverse ,section on the line |1-I1, Fig. 14.

Fig. 18 is a transverse section on the line I B-IB, Fig. 14.

Fig. 19 is .a transverse section of y the line IB-IS, Fig. 14.

Fig. 20 is a perspective view of the upper base shown in Fig. 2.. t

Fig. 21 is a perspective view of the lower base shown in Fig. 2.

Fig. 22- is a perspective outside view of the shell shown in Fig. 2.

Fig. 23 is a longitudinal section in perspective of the female membersof the clutch shown in Fig. 10.

Fig. 24 is a perspective view of a portion of the male clutch members ofthe clutch shown in Fig. 10.

The same reference characters are employed to refer to the same orduplicate parts throughout the several views. y

The sections 8-8', and 9'-9, Fig. 11, while the same in form as thesections 8-8, and 9 9, respectively, Fig 3, are differentiated therefromto avoid confusion in the reference numerals which are different forsome of the parts cut by these sections.

In Fig. 1, the preferred form of the invention is shown inserted in awell bore a, with the fish tail bit I hanging in the well, the packer 2being positioned proximately above the formation to be tested c.

'I'he dotted lines 2a indicate the packer expanded into sealing offengagement with the well formation after the latch has been sprung, bymeans of a cable attached to pull bar 38,

. means being provided to attach and detach' the cable from the vpullbar when necessary to expand or contract the packer, as required. Themeans for attaching and detaching the cable from the pull bar is notshown because many tools for such purpose are old and well known in theart. That part of the well bore between the'bit and bottom of the wellb, indicated at j, shows that the device may be positioned anywhere in`a well bore and that no anchor string is required to support the packerfrom bottom of the well.

The outer shell of the device having limited telescopic movement overthe next inner string, is constructed of cap I 1, nipple 20', couplingnipple 2|, nipple 22, coupling member 24, nipple 25, coupling nipple 2G,nipple 28, packer shield coupling 29, packer nipple 30, having weld 29h,whereby this nipple may be secured to member 29 for convenience inassembling and taking the device apart; sleeve nipple 3l, nipple 32,cable l animes' anchor member 33, nipple 3l, coupling 3l welded nipple38, coupling 31, and

to nipple 38 at 38a; bit i The inner string, adapted to have limitedtelescopic movement within the outer shell, has its uppermost positionupon the shell determined by the engagementof balls lll. Fig. 2, withinthe pockets le at the lower end of slots 1c in the clutch shell 1, Figs.2 and 22. T'he lowermost position of the inner string is limited by theengagement between balls and shoulder 'la of clutch shell 1. 'I'hisinner string is formed of nipple 8, which may be threadedly Joined tocoupling l and drill stem 3, Fig. 1, above it, and also threadedlyjoined to nipple 8, having special wrench slots 8a, below it. c

Continuing downward, the other members of xthe inner string are clutchshell "l, nipple 8,

bearing support 3, bearing housing nipple I0, and intake"v,alve nippleIl, having' intake ports Ila. In each form of the invention, the drillstem will be considered as extending to and including the nipple, havingintake ports Ila.

The packer 2, which may be of rubber or any other strong, durable, andexpansible substance,

` loosely fitted over the nipple 30, has its tapered paint, glycerine,or heavy oil.

.is forced downward, in a manner to be explained,

ends 2c closely received within the circular metallic cups or shields29a and 68, respectively. The grooves 30a, 29e, and 68a provide that thepacker wlllhave secure engagement with the surfaces in which thesegrooves yare formed when theY packer is urged against them with greatforce. The reinforcing rings 2b, preferably of steel, may be mouldedinto the packer proximate the inner ends of retaining cups 23a and 68.The member 88, threaded upon sleeve 8l, has packing i0 between its lowerend and locking ring 69, for the purpose of preventing fluid under highpressure, within the annular chamber e, from escaping through the slightclearance between shield member 68 and, nipple 30 and along the threadsbetween member 88-3I. The threaded engagement between members 68 and 3lprovidesmeans for causing the tapered ends of the packer to be tightlyengaged within their respective cups or sleeves, as is apparent. Thetapered ends 2c of the packer may each be six to eight inches long. Thedistance between the steel rings 2b may be ten to eighteen inches. Thethickness of the packer walls between the rings should be at least asmuch as the clearancebetween the packer and the well bore, and should beconsiderably thicker if diameters will permit. The clearance between thepacker and the wall of the well bore may be, ordinarily. threeeighths tothree-fourths inch all around the packer.

The piston base 6I, threadedly engaged upon being spaced apart by endcup spacers 83, having peripheral grooves 83a; and central cup spacers64, having peripheral grooves 64a. The cups and spacers are secured intheir assembled position, as shown, by piston assembly clamp 66 engagedupon washer 65. 'This assembly, which'has a close sliding fit withinnipple 28, will be referred to as piston lil-68. It will be understoodthat the annularchamber e should be lled with a liquid, preferably of aviscous nature, such as When the piston the uid in chamber e is forcedout through openings 30h, this fluid expanding the yieldable packer intostrong leakproof engagement with the wall of the well bore, as indicatedat 2a, Fig.

ings they would. of course, be damaged.

4within nipple4 5, hold the member 38 centrally lsame manner as thepacker would be expanded 1. The chamber e may be 'illled-or'drain'edthrough the openings shown closed by plugs 11,

as is apparent in Fig. 3. Manifestly, the effective area of piston 8|`88should be such that the packer will be expanded far enough to securely 8engage the adjacent formation before the clamp".y ,i ring 38 will landupon the shoulder 28d, this shoulder being provided to arrest thedownward movement of the piston before the cups 82 can reach theopenings38h, in passing which opten- I is also apparent that the same forceexerted to drive the piston downward will cause greater pressure inchamber e, and at the same time l cause ample expansion of. the packer,if the eil'ec- 16 tive area of the piston be made less and its travelincreased. The cross sectional area of the annular space between thenipples il and 28 is the effective area of the piston 8I-88, as appearsin Fig. 2.

It will be noted that pull tube 4I, having perforations 4| a, has itsbottom end threadedly engaged within the central opening through thecable anchor 33, the engagement between' these members being secured bya lock nut 42, and 25 further secured by clampfnut engaging upon thelower end of member 33. The winged coupling 39 has threaded connectionbetween-pull tube 4I and pull bar 38. Wings 39a, slidable 30 alignedwithin nipple 5 for convenience in ,attaching thereto and detachingtherefrom the overshot or other means used on a cable to manipulate thepiston and packer. It will be noted that pull tube Il, through itsconnection with cable anchor 33,is adapted to holdor raise the outershell of the device, upon which the packer is mounted, by means of acable which may be removably attached to pull bar 38. It is, therefore,apparenty that the outer shell of 'the device may be stopped oranchored, independent of the inner string of the device, at any place inthe well bore, by merely attaching a cable to pull `bar 38, and making-the cable fast above the drill stem. Means for attaching a cable to theupper end of bar 38, after it has been lowered into the well, and. ofdetaching the cable therefrom, at will of the operator, are not shown inthis application because, as stated, such means are old and well knownto the art.

If a cable be attached to pull bar 38, and the upper end of the cable bemade fast, it is evident that lowering the drill y stem will forcepiston lil-86 downward an-d expand the packer in the if the bit vwerelanded on bottom of the well. When the drill stem is so lowered, nippleII has telescopic movement over pull tube 4 I, Figs. 2 and y, 3. Packingl2b, washers I2a and gland clamp nipple il, has cups 82 mounted upon it,the cups I2 provide a leakproof engagement between these members, asshown in Fig. 3.'

While expanding the packer, it is evident that the fluid in chamber emust be prevented from escaping therefrom, except through openings 30hcommunicating with the interior of the packer. This chamber is caused toso confine the liquid, by means of ring shaped U cups 1-|, Fig. 3, andpacking, or other substance, placed or allowed to accumulate in grooves3io within the central opening through sleeve nipple 3|, it beingunderstood that the lower end of nipple Il has a close sliding fitwithin this' opening and through the cups and/or packing which engagebetween they members Il and 3| as shown in Fig. 3. It is also apparentthat the tapered ends 2c, respectively,

of the packer wilibe urged with Agreat force 25 chamber cap I1 and afree sliding flt withinl y the circular groove |1a-I9a within whichgroovesleeve I9 and nipple 2II. A packing I9, contained within anannular recess in the central opening through latch chamber cap I1,engages with the piston member 5. Well fluid pressure contacts thispacking via pressure ports I1b, chamber d, discharge ports Ila, andrubber band I6, in order to make leak proof the engagement betweenmembers l andv I1 during the telescopic movements between these membersin the operation of the device.

The latch balls 52, Fig. 2, are received to slightly less than one halftheir diameter within they are normally held by the expansive force ofspring I9, having its lower end supported by internal flange 24a.SpringI cap 54, Qball floor support SII, and ball `floor ring II, whichmay be of hardened steel, transmit the force of this spring to theballs, which are normallyimpinged between ball rider ring 53, threadedlyengaged over the nipple 6, and ring I.

This ring has its upper end formed by two surfaces, each at a differentangle. The outer angle surface 50a engages with the balls while they areimbedded within the recess I1a-I9a, as shown in Fig. 2. The inner anglesurface 50h engages the balls when they are forced out of said recess bydownward thrust of the drill stem, thisl thrust being imparted to theballs by ring 53, -which may be of hardened steel. The sleeve I9, whichmay be of case hardened steel, has an easy removable fit within thenipple 2II and is normally held in the position shown by the threadedengagement between nipple 2li and 2I.

Manifestly, the greatest latching force will be exerted by the latchwhen balls 5I are engaged within the circular recess Il1a--I9a to themaximum depth of this recess. 'I'his latching force may be diminished byscrewing the nipple 2I upward upon the nipple 22, thus forcing the latchballs inward and partially out of the recess I1a, -I9a. When the desiredadjustment has been obtained, locking Yring 23 may be employed to securethe adjustment. In this connection, it may be observed that clutch balls40, normally engaging within pockets 1e at lower ends of slots 1c, willprevent any upward movement of ball rider ring'53 when nipple 2l isscrewed upward. It is, therefore, apparent that the latch may beadjusted, as stated. Care should be exercised that recess I1a-I9a hasslightly less depth than one half the diameter of the balls, for thereason that the latch balls would become locked against I downwardmovement, and thereby render the latch inoperative, if the depth of thisrecess were equal to, or greater than, one half the diameter of theballs.v y

When the latch springs, the balls roll inward and ride downward withinthe nipples I9 and 2|. In this travel, the inner angle surface 50h urgesthe balls outward with enough force to safely cause them to roll outwardand again engage within the recess I1a'-I9a when the latch returns. Inthe meantime, this force is not great enough to cause the balls todamage the inner surfaces of nipples I9 and 21|.

The chamber a may be filled with a lubricant to provide lubrication forthe latch and clutch. This lubricant may be supplied through theopeningsvshown closed'by plugs 19 and 19, Fig. 2.

The spring 49, in addition to. furnishing the necessary force for thelatch, also serves to yieldably maintain 'the device in its normal ormoet elongated position. p

'I'he clutch, in Fig. 2, is shownvin its normal engaged position. Thisclutch is formed of shell 1, balls 40, upper ball socket base 5l, andlower ball socket base 59. The upper base, having slots 95a, Fig. 20,for circulation of a lubricant within the annular chamber a, maybepressed into nipple 29 and landed upon the internal shoulder 29a, theilutes 55e being imbedded within the inner wall of this nipple. Thelower ball socket base' 59, having circulation slots 56a similar to`,and aligning with, the slots Bla," is fitted loosely within the nipple28 for convenience in taking the clutch apart. 'I'he base i8 is held inplace by the threaded engagement between members 2l and 28, as appears.The clutch balls 49 are received for one half of their diameter withinthe sockets 55h-59h, Figs. 20 and 21, and extend for the other half oftheir diameter-into the slots 1c formed by the ribs 1f and 1d. Theseslots, like the sockets, have a common depth equal to approximately onehalf the diameter of the balls. The slots are open at their upper endsand closed at their lower ends where they are formed into pockets 1econforming to the balls.

'I'he portion of reduced external diameter 1b forms the annular chamber1a,'also having a uniform depth equal to one half the diameter of theballs. 2

The upper portion of shell 1 immediately above the circular shoulder 1ahas slight clearance. such as n" to within the nipple 25, this clearancebeing for the circulation of a lubricant, which preferably should beplaced within the chamber y for the latch and clutch, and also toprovide lubrication for piston Sl-BG in its return travel at conclusionof the test.' The slots 1h and 1h', Fig. 22, are also for circulation ofthis lubricant. The balls I0, while free to rotate in their respectivesockets, cannot leave these sockets, because, as stated, the slots 1cand annular chamber 1a have a common depth of one half the diameter ofthe balls. 'I'he lower base 58, otherwise free, is locked to upper baseby the balls imbedded equally within the mating 'I'he downward movementoi.' the inner stringA which actuates the piston BI-SS to causeexpansion of the packer, places the annular space 1g opposite the balls40. 'I'his movement unlocks the clutch. The drill stem may be thenfreely rotated upon rollers 61, leaving stationary the outer shell,packer, and all other parts below the thrust bearing. The clutch isalways so disengaged while the device is intaking test fluid, becausethe tool is designed so that the piston travel necessary to expand thepacker into engagement with the well formation is' always greater thanthe'length of the slotted portion of clutch shell 1.

At conclusion of the test, there is no danger that the ribs may impingeupon the balls, due to some possible error in spacing the upper wedgesmoes shaped ends ofthe ribs. because one rib 1f, is

longer than the others and, therefore. acts as a pilot to guide theother ribs between the balls.

The flange 8a engaging under the flange I 8a vcauses the nipple 8 tohold the bearing 81 upon beginningof each test made with.either form ofthis invention. The check valve assembly consists of check valve clampnut 43, Fig. 3, having valve seat 43a; valve cage I3, having slots I3a;ball check valve 44, ball support 45, spring 48, spring shoe washer",and spring adjusting stud 48. Valve 44, yieldably held against its seat43a by spring48, prevents well fluid from entering the drill stem. butallows that pump uid may be discharged through the drill stem via slots13a,

vone inch, for example.

nipple 34 opening h. by the gadget box or instrument case nipple 38, andout through passages Ia of the bit. Pump uid immediately before reachingthe check valve takes a path through passages 4Ia and tube 4I. Ballsupport 45 has a close movablet within cage I3 andslots I3a have` theirupper ends somewhat below the upper end of \ball support 45.` Thisdistance may be The ball check valve, therefore)` will be one inch fromits seat before any punjip fluid can escape through slots |3a.Consequently, the valve and seat will not be greatly damaged by abrasivesubstances usually present in the pump fluid. The compression force ofspring 46 may be adjusted by stud 48, as is apparent.

The intake nipple Il has intake ports I la, Fig. 3, normally closelysheathed. within the lower end of the central opening through sleevenipple 3|. When the drill stem forces the piston 6I-66 downward, thenipple I I, upon which this piston is engaged, travels downward farenough to unsheath the intake ports Ila. Well iiuid from below thepacker may then enter the drill stem via inlet opening 32a, space f, andports IIa. The same drill stem movement which raises the piston Iii-66and releases the packer at conclusion of the test, also re-sheathes theports Ila, as is apparent.

The iiare chamber d, Fig. 2, which may bey filled with a are or telltale iiuid distinguished in color from the well uid, is formed withinthe sleeve I4, which has a close sliding fit over nipple 2D. Lockingring I5, having threaded engagement over the piston nipple 5, serves tosecure the similar |engagement between members 5 and I4. On the downwardstroke of the drill stem, the flare fluid is discharged through openingl4a and past rubber band I6. AI'he packer 2 being expanded at the sametime that this flare iluid is discharged into the well bore above thepacker, it is obvious that flare fluid will be found in the drill stemif the packer should fail to effect a complete seal-oil with the wellformation. 'I'he test is thus made truthful about where the test iiuidcomes from. On the upstroke of the drill stem, rubber band I6 will yieldor rupture to allow well iuid to be drawn into the chamberV d. This wellfluid, of course, may be drained through openings I4a, and chamber dreiilled with viiare iluid through the same `-vopenings when Vthe drillstem is withdrawn. y a

The instrument case 'I2 mayfbe welded into a nipple 38 and coupling 3lby welds 38a, having central openings )Sb through them. `these openingscommunicating between the interior oi the instrument' case and the wellbore. lThe lid 18. by which the instruments may be placed into orremoved from the case, is engaged upon pack- Ing 'I6 by studs 14,secured upon case 12v by welds 14a, and nuts 15, in order that alloutside communication with the interior of the instrument case will bethrough openings 38h. Within this case suitable instruments may beplaced for the purpose of recording pressures and temperatures andchanges therein while the device is ,being lowered into the well, whilethe test is on, and while the device is* being withdrawn from the well.Such instruments being provided, many of which are available, theoperator sees that his watch and the timing mechanism of the instruments agree. A record of the time is kept when running the device in,when it is intaking, and when being withdrawn. The operator then ord.I'his check should reveal lthe place in the well where all recordinginstrument data was made.

In operation, the device lis secured upon the drill stem 3 by means oflcoupling 4. and lowered into the well bore until the packer ispositioned at a point opposite, or slightly above, the formation to betested. this'formation being indicated at c, Fig. 1.

Obviously, all formations below the packer will be on test. If, however,it is desired to separately test any particular formation, to theexclusion of all other formations, it will be necessary to conduct twotests. The tlrst test should be made by setting the packer immediatelyabove the formation to be tested. In the second test, the packer shouldbe set immediately below this formation.

'I'he difference between the two tests will disclose the quantity andcharacter of fluid enter- Ing the well bore through the formationbetween the horizons where the packer was set for both tests.

thousand to three thousand and twenty feet, it being assumed that thereare also numerous other sands in the formation which may be discharginginto the well bore below three thousand feet. In order to test the sandbetween three thousand and three thousand and twenty feet, the packershould be set at, or slightly above three thousand feet forP the ilrsttest; and again set at three thousand twenty feet, or slightly below,for the second test. If the first test should reveal that all formationsbelow three thousand feet were producing at the rate of one thousandbarrels per day, and if the second test should show that all formationsvbelow three thousand twenty feet were producing at the rate of iivehundred barrels per day, it -becomes evident that the sand between threethousand and three thousand twenty feet is producing the other fivehundred barrels per da The device being lowered into proper position. asabove stated, a Vcable having some vform of overshot to engage pull bar38 is lowered into the drill stern until suchengagement is made. Thecable is then tightened to securely anchor the outer shellof the deviceand made fast, at the top of the well until the test has been completed.Here it should be recalled that pull tube 4I is attached to the outershell by means oi' To illustrate, the well is four thou-- sand feetdeep, and there is a sand from three.

lchecks his instrument charts with his time reccable anchor 38, asappears in Fig. 3. The drill stem is now lowered, at which time thelatch springs, the clutch disengages, piston 8|-66 forces the fluid inchamber e out through openings 80h to expand the packer and, at the sametime, uncovers intake ports la.

The test is then on, well fluid from below the packer at this timeentering the drill stem through inlet ports 82a, annular space ,f andintake ports I la, as heretofore explained. The duration of such testsmay be for any desired period of time, fifteen to forty-nve minutesbeing usual.

At the conclusion of the test, the cable is given slack. Pressure ofWell fiuid'instantly compresses the packer to again engage: upon nipple80 and force piston 8|-66 upward while, at the same time, the expansiveforce of spring -48 aids in forcing the outer shell of the devicedownward, whereupon intake ports ||a are instantly closed and the latchand clutch become again engaged. Cable 80 is then released from pullroci 88, whereupon the well fluid which entered the drill stem duringthe test may be recovered, either by withdrawing the drill stem or bybailing or swabbing the test fluid out of it. If the test uid be bailedor swabbed out, only a few minutes will be required for this operation;whereupon the device may be raised or lowered and other tests made inrapid succession, as heretofore stated, and as is apparent. It will benoted, however, that the drill stem must bewithdrawn in order to refillflare chamber d, but the well uid drawn in through rubber band |8 andports |4a will be impregnated with enough flare uid to cause the flarefeature to be effective during three or four tests after each filling ofthis chamber. s

If the operator is careful to record the tim during which repeated testsare made, the recording instruments may be relied upon to discloseaccurate information throughout the several successive tests.

In the first modified form of the invention, illustrated in Figs. 10 andll, I set out a device similar to that shown in the preferred form,except that the piston whichds employed to expand the packer is forceddownward by a weight lowered into the drill stem by means of a cable. Atconclusion of the test, raising the weight causes the pressure of wellfluid to contact the packer and restore all parts to the position shownin Figs. 10 and 11.

No flare means is shown provided for this modification and no latch isdeemed necessary.

While being lowered into or withdrawn from the well, the entire devicemay be rotated with the drill stem, and may be pumped through at anytime. The drill stem may be rotated independently of the device, whichremains stationary during the test, as in the preceding form.

The outer shell of the device consists of a cap 88, stufilng box base85, lower clutch shell housing nipple 86, nipple 81, coupling sleeve 88,having ribs 88a and internal grooves 88h; packer nipple 88, packer upperend shield 8|, secured upon nipple 88 by weld 8|a; nipple 82, sleeveconnection 83, nipple 84, check valve cage 86, nipple 88, coupling 81,gadget box housing nipple 88, coupling 8l, and bit I.

The inner string of the device consists of clutch male member |80,nipple |0 coupling |02, intake nipple |08, connection member |88 andnipple |08. The uppermost position of the inner string with reference tothe outer shell will be determined by the engagement between nuts H3 andthe lower end of connection 88. The lowermost position of the innerstring with reference to the shell will be determined by the en gagementof circular flange |00d upon the upper end of sleeve 88.

'I'he packer 2, Fig. 10, loosely engaged over nipple 88, has its endsengaged between the shield members 8| and 68. Fluid in the chamber e isforced to expand this packer through ports 80h, in the same manner aswas described for the preferred form of the invention, to whichreference is made for al1 information concerning the packer and itsinstallation. Obviously, the chamber e' may be filled or drained throughthe openings shown closed by plugs 80, as was stated for the preferredform.

The packer is expanded by downward movement of the piston members,mounted upon nipple |03. The split ring |01, engaging for one half ofits depth within an annular recess upon nipple |03, has engaged over itthe lower end of base member |06, having grooves |06a, as appearsin Fig.10. Packing |05 and spacers |05a are secured in the position shown bypiston clamp |04, having grooves |04a. This piston will be referred toas piston |04|0|. A weight 8| is lowered by means of a cable 80 shown inFig. 1, to force this piston downward and expand the packer. Ring shapedU cups 1|, surrounding the central opening through the lower internallyupset end of nipple 88, closely engage the nipple |03, which has a closesliding t through this opening.

A simple form of clutch is shown proximate the upper end of Fig. 10. Thedrill stem connection member 88 has an external flange 88a, rotatablyengaged between the shoulder 86a and the upper end of member 86. Aseries of equally spaced keys 88b, Fig. 23, having lower wedge shapedends 88o, are formed interior of the lower end of member 88. The member86h has an equal number of equally spaced similar keys 86e, with similarwedge shaped lower ends 86d. The members 86 and 86h may be threadedlyjoined together for manufacturing convenience, in which position theyare shown secured by welds The male member |00 of this clutch also hasan equal number of similar equally spaced keys I00a, having similarwedge shaped upper ends, which keys having an easy sliding fit betweenthe female keys 86o and 88b, will normally lock .the members 85 and 86together, as shown in Fig. l0. When the weight 8| is let down upon theupper end of clutch male member |00 where it engages upon its seat |000,the keys |00a will be forced below and out of engagement with the keys88h and 86C. This movement disengages the clutch. The drill stem maythen be rotated independently of the packer and outer shell of thedevice. Packing 84, compressed by gland 82, forced downward'by cap 83,maintains the clutch leakproof against entrance of well fluid.

When the weight is lifted, the pressure of well fluid external of thepacker will force the .packer inward, causing the fluid in cham'ber e'to force the piston |04|01 upward and reengage the clutch. It will benoted that one .key |00b, Fig. 24, is longer than the others,

which are of equal length. 'I'his long key` acts as a pilot to guide themale member of the clutch into locking engagement, first with the 'lowerkeys 86c, and then with the upper keys 8812. 'I'hese two sets of keysare shown out of ter of six inches, by a length of thirty inches,

alignment, for illustration, in Fig. 23. but by the actionof the pilotkey Illb, both seta of female keys will be aligned and the clutchagainengaged or locked when the piston 'returns toits upper positionafter weight 8| has been lif from the clutch male member |00.

Check valve cage 35,Flg. 11, has a central opening around the lower endof which valve seat 95a is formed to receive'check valve H4. The checkvalve support IIS has arms ||3a engaging upon coiled spring ||8installed under' enough compression to securely seat the valve.

'Ihis spring rests upon, and may have its compression adjusted by springbase ring V| Il. When necessary to Vpump through the drill stem, as maybe done in the same manner as was stated` for the preferred form, thisvalve will yield to allow the pump fluid to be discharged through theopenings la of the bit, as is apparent. At all other times, this valve,of course, will lrte-- main closed by the force of spring H8, plus thepressure of well liquid exterior of the device, which liquid will exertpressure under the valve` via openings la oi' the bit.

It is apparent that intake ports Ila, Fig. l0, will pass out of thelower endY of nipple 39 when the piston |04|0`| is forced downward tocause expansion of the packer, as explained for the preferred form. Wellfluidl from below the packer then enters nipple |03 through these portsvia annular space 7c and inlet ports 32a, and passes thence into thedrill stem through openings ||a, at which time weight 8| is engaged uponseat |00c and thus closes the opening through clutch member |00. Whenthe intake ports Ila are sheathed as shown in Fig. 10, the closeslidable t which nipple |03 has within the central opening through thelower end of nipple 89, and the action of check valve ||4 exclude allwell fluid from entering the drill stem, which, of course, should beempty at beginning of the production test.

The instrument case, indicated generally at G, within nipple 88, Fig.11, is similar in construction and identical in purpose with theinstrument case shown and discussed in connection with the preferredi'orm of the invention, and, is shown again only to avoid breaking thedraw- Ports 89a, Fig. 10, allow well iiuid to enter the annular space nand press downward upon piston |04-|01. The close movable t which nipple|0| has within the central opening through member 88, and similar fitwhich the piston has "within nipple 89, serve to prevent the escape ofthis iluid into the drill stem `or into the annular space e'.

'I'he chamber m, Fig. 11, is empty when the drill stem is lowered intothe well. Packing ||2, compressed by gland III, forced downward by clamp||0 and grooves 93a, which may be filled with packing, serve to excludewell iluid entering the annular space Ic through ports 92a from thechamber m. `Well pressure will be equal above the piston and outside ofthe packer. Weight 8|, which may be a string of steel rods orbars, willexert the necessary force to expand the packer. To 'illustrate this, itwill be assumed that Weight 8| weighs two thousand pounds, and thattheeil'ective area of piston inl-|01 is four square inches; consequently,this weight will cause the packer to expand by a pressure of ilve-hundred pounds per square inch exerted upon the entire inner surface ofthe packer. If the packer has a central diameweight 0|, therefore, willexert a total force of 282,600 pounds to expand the packer. v

Subject to the employment of a diilerent clutch I and a diilerent packerexpansion means above described, it will be understood that theoperation oi' this first modified form of the invention j is so similarto that of the preferred form asV racks dlsposedcn opposite sides of adouble' pinion.

From, and including, the packer downward, this device may be the same asthe iirst modiiled form. For that reason the lower part of this.construction is not shown in connection with Fig. 14, but reference ismade to Figs. 10 and 1l for parts not shown in Fig. 14.

The outer shell, inV Fig. 14, consists of bushing,

i8, nipple H9, connection member |20, and packer nipple 2|.

The inner string, upper section, which has limited 'movement independentof the outer shell, is formed of rack shell |23, single rack |22, doublerack |21, and driving shoe |35. The maximum travel of this section islimited by the length of the racks.'

'I'he inner string, lower section, is formed of intake nipple |4| andthe packer piston parts shown mounted upon it. The travel of thissection is controlled by the uppersection, as is apparent. The packer,Fig. 14, indicated generally at P, is the same in construction andoperation as the packer shown for the ilrst modified form, to whichreference is made. The double pinion |28-I29 may be cast or otherwisemade in one piece. 'I'hese pinions are mounted within gear case nipple||3 by axlepin |30 secured as shown by cap screw |3|, Fig. 17. Thesingle rack |22, having teeth I 22a, adapted to engage between themating teeth |28a of the larger pinion |28, is secured within rack shell|23 by bolts |24 and nuts |24a. The rack shell |23, in addition tohousing and carrying the rack |22, has neck |23b, reenforced by 'rib|23a, against being deformed when the head |23c, attached by coupling|23d,

is pulled upon by the cable, as will be explained. The double rack |21,having teeth |2la adapted to engage between the mating teeth |29a of thesmaller pinion |29, has rib |2'Ib to reinforce its thrust shaft end |210to the lower end of which driving shoe has threaded engagement. y

The opening I 21d, Fig. 16, freely receives the pinion |28, as clearlyappears in Figs. 14 and 17. The landing shoe |35c is guided centrallyupon piston member |36 by wings |35b, having an easy sliding ilt withinnipple |,2|. The diameter of pinion |28 is such as will so space the tworacks apart that these racks will each have a free sliding clearancewithin the nipple H9. Top plate |42, threadedly engaged within the casenipple H9, and base plate, |32, also having threaded engagement .withinnipple l I3, serve to house the racks and pinions.. The chamberq thusformed may be illled with oil vor .other lubricant. The' neck |23b has aclose sliding t within the central opening through plate |42 and shaft|21c` ing or other substance.

the central annular extension of plate |32 in order to more securelyconfine the lubricant within chamber q. Packing |43 engaged by gland|34, may be compressed by cap |33, as appears in Fig. 14. The tubes |25,Figs. 14', 15, 16, 17, and 18, so spaced as to .offer no interferencewith the action of the racks and pinions, are secured upon and withinthe plates |32 and |42 by the rolled out or expanded ends |25a engagingunder plate |32 and by nuts |26 engaging upon plate |42.

While the device is intaking test fiuid from the weil formation, in amanner explained for both preceding forms, the well fluid passes throughthe central opening in shoe |35, out of openings |35a, and up into thedrill stem through tubes |25. If it should be necessary to pump throughthe drill stem to clear the well bore of mud or other obstruction, thismay be done, as explained for both preceding forms. Pump fluid, inpassing through the device, will take the same path as the one indicatedfor the test fluid except, of course, in reverse direction.

The piston member |36, threadedly joined upon the upper end of nipple|4|, has mounted upon it cups |31, cup spacers |38, piston assemblyvclamp |39, and packing |40, as appears in Fig. 14. The grooves |36a maybe filled with pack- Passages |390l and |39b communicate between thechamber e and inner side of the packing, for the obvious purpose ofcausing this packing to firmly engage within nipple |2| by the forceemployed to drive the piston downward. Great force may be exerted uponthe piston by the racks and pinions. If, for example, the ratio betweenthe pinions is 2V; to l, a cable pull upon head |23c of ten thousandpounds will drive the piston downward by twenty-five thousand pounds. Ifthe effective area of the piston is five square inches, five thousandpounds per square inch will be exerted to expand the packer.

In operation, the device is lowered into position upon an empty drillstem, as explained, for the preceding forms. A cable, having upon itslower end an overshot or other tool capable of engaging uplon the head|230, is let down and so engaged. The required pull is exerted upon thecable for the duration of the test. The cable is then released from head|230. Pressure of well fluid exterior of the packer then pumps .thepiston back and causes all parts to return to the positions shown;whereupon the test fluid may be bailed out, swabbed out, or recovered bywithdrawing the drill stem, as in the other forms. If, as stated for theother forms, the test fluid be withdrawn by bailing or swabbing,successive tests may be made with this device in rapid succession, bymerely raising or lowering it and manipulating the cable, as explained.It is understood that all references to positions and directions, suchas upper and lower," upward and downward," above and below," apply tothe tool as illustrated in the accompanying drawings wherein the upperportion of the tool is shown uppermost.

While I have shown and described the preferred embodiment of myinvention it will be understood that the same are illustrated examplesonly and are not intended to limit minor variations in the constructionand apparent uses of the device.

What is claimed is:

1. A well testing tool comprising in combination an outer shell, apacker thereon, fluid pressure means to expand said packer, a, drillstem releasably connected` to said' shell, a pullmember fixed to saidshell, and means operable from the surface to engage said member toanchor said shell so that subsequent downward movement of said drillpipe will actuate said first `means to expand said packer.

2. A well testing toolcomprising in combination an outer shell, a packerthereon, fiuid pressure means to expand said packer, a drill stemreleasably connected to said shell, a pull member fixed to said shell,means operable from the surface to engage said member to anchor saidshell so that subsequent downward movement of said drill pipe willactuate said first means to expand said packer, and ports on said shelland stem to communicate after setting of said packer.

3. A well testing tool comprising in combination an outer shell, apacker thereon, fluid pressure means to expand said packer, a drill stemreleasably connected to said shell, a pull member fixed to said shell,means operable from the surface to engage said member to anchor saidshell so that subsequent downward movement of said drill pipe willactuate said first means to expand said packer, and clutch means betweensaid stem and shell releasable by the downward movement of said pipe torelease the pipe from said shell for rotation. I

4. A well testing tool comprising in combination an outer shell, apacker thereon, fluid pres-sure means to expand said packer, a drillstem releasably connected to said shell, a pull member fixed to saidshell, means operable from the surface to engage said member to anchorsaid shell so that subsequent downward movement of said drill pipe willactuate said first means to expand said packer, and latch means betweensaid stem and shell to indicate to the operator that said stem isreleased to actuate said pressure means to set said packer.

5. A well testing tool comprising in combination an outer shell, apacker thereon, fiuid pressure means to expand said packer, a drill stemreleasably connected to said shell; a pull member fixed to said shell,means operable from the surface to engage said member to anchor saidshell so that subsequent downward movement of said drill pipe willactuate said first means to expand said packer, ports on said shell andstem to be aligned after setting of said packer, and latch means betweensaid stem and shell to indicate to the operator that said stem isreleased to actuate said pressure means to set said packer. I

6. A tool of the character described including a drill pipe, a shellfixed thereto, a packer on said shell, a reservoir in said shell forliquid to expand said packer, a piston assembly movable within saidshell independently of the movement of the drill pipe to force liquidfrom said reservoir into said packer, and means operable within saidpipe to move said piston assembly.

7. A tool of the character described including a drill pipe, a shellfixed thereto, a packer on said shell, a reservoir in said shell forliquid to expand said packer, a piston assembly movable within saidshell to rforce liquid from said reservoir into said packer, meansoperable within said pipe to move said piston assembly, and ports onsaid assembly and shell communicating by such movement to admit a sampleof well fluid after setting of said packer.

8. A tool of the character described including a drill pipe, a shellfixed thereto, a packer on said shell, a reservoir in said shell forliquid to expand said packer, a piston assembly movable within saidshell to force liquid from said reservoir 'into said packer, and meansoperable within said pipe to move said piston assembly, said meansincluding a removable weight.

9. A tool of the character described including a drill pipe, a shellfixed thereto, a packer on said shell, a reservoir in said shell forliquid to expand said packer, a piston assembly movable within saidshell to force liquid from said reservoir into said packer, meansoperable within said pipe to move said piston assembly, ports on saidassembly and shell to be aligned by such movement to admit a sample ofwell fluid after setting of said packer, and clutch means connectingsaid pipe and shell, which clutch is operable to release said pipe forindependent rotation relative to said shell, said means also beingoperable by movement of the pipe.

10. A tool of the character described including a drill pipe, a shellfixed thereto, a packer on said shell, a reservoir in said shell forliquid to expand said packer, a piston assembly movable within saidshell to force liquid from said reservoir into said packer, and meansoperable within said pipe to move said piston assembly, said meansincluding a cable.

11. A tool of the character described including a drill pipe, a shellfixed thereto, a packer on said shell, a reservoir in said shell forliquid to expand said packer, a piston assembly movable within saidshell to force liquid from said reservoir into said packer, and meansoperable within said pipe to move said piston assembly, said meansincluding a cable and a rack and pinion device.

12. A combination well testing and cementing device including anoperating string of pipe, a shell surrounding a portion of said pipe andadapted to have telescopic movement over it, means upon the lower end ofthe pipe to lift the shell, an adjustable latch connecting said shelland pipe, said latch being operable by weight of said pipe incombination with the pulling force of a cable, a hydraulic packermounted on said shell, a piston within the shell, said piston beingadapted to be operated by the pipe and the cable, intake ports in saidshell normally out of communication with similar ports in said pipe, apull tube attached to the shell below the intake ports and having a pullbar attached to its upper end adapted to be engaged by a cable means forsupporting the weight of the pipe upon the shell,

said tube having openings for pump fluid, a cablev adapted to beanchored at the top of the well and to be releasably engaged with thepull tube, packing means between the pull tube and the pipe proximatelybelow the intake ports of the pipe, a latch engageable between the pipeand the shell, a clutch means between the shell and the pipe, saidclutch being adapted to permit limited tele,- scopic movement betweenthe pipe and the shell after the latch is sprung, said clutch beingfurther adapted to permit rotation of the pipe relative to the shellafter a predetermined telescopic movement between said members,` saidclutch having one guide rib longer than the others acting as a guidetofacilitate reengagement of the clutch, a thrust bearing in the pipebelow the clutch, a piston upon the pipe, said piston being operablewithin the shell, a chamber full of fluid under the piston, said uidbeing adapted to be forced through openings in the shell and into apacker for the purpose of expanding the packer against the well bore orcasing, a flare-ud chamber filled with a 4telltale substance adapted tobe forced into the well bore or casing above the packer when the packeris expanded, a check Valve upon the lower end of the pull tube, saidvalve being adapted to be opened by pump fluid in the pipe, aninstrument case inthe shell below the packer,'and a drill blt upon thelower end of the shell.

13. An operating string of pipe, a, shell surrounding a portion of saidpipe and having limited telescopic movement over it, an adjustable latchconnecting said pipe and shell, a hydraulic packer mounted on saidshell, a piston Within the shell, said piston being adapted to beoperated by the pipe and a cable, intake ports in said shell normallyout of communication withfsimilar ports in said pipe, a pull tubeattached to the shell .below the intake ports and having a pull barattached to its upper end adapted to be engaged by a cable means forsupporting the weight of the pipe, said tube having openings for pumpfluid, a cable adapted to be anchored to the top of the well and to bereleasably engaged with the pull tube, packing means between the pulltube and the pipe proximately below the intake ports of the pipe, aclutch between the shell and the pipe, said clutch being adapted toprevent rotation of the pipe and shell relative to each other until thepipe has been moved perpendicularly a predetermined distance relative tothe shell after which movement the pipe may be rotated independently ofthe shell, a thrust bearing in the pipe below the clutch, a. piston uponthe pipe,-said piston being operable within the shell, a chamber full offluid under the piston, said iiuid being adapted to be forced throughopenings in the shell and into a packer for the purpose of expanding it,and means for withdrawing the device, pipe and sample of well iiuid fromthe well.

14. A combination well testing and cementing device including anoperating string of pipe, a shell surrounding the pipe and adapted tohave limited telescopic movement therewith, a packer mounted on saidshell, a clutch coupling between the pipe and the shell, a tube attachedto one member of the clutch and extending downward therefrom 'and havinglateral openings for pump fluid, said tube having means attached to itslower extremity to limit upward movement thereof in order to controlengagement of the clutch, intake ports in said tube normally out ofcommunication with similar ports in said shell, the ports of the tubeand shell being adapted to become in communication with each other whenthe piston is forced downward, packing means between the tube and theshell below the intake ports, a piston assembly on said tube slidablewithin the shell, a chamber lled with fiuld under the piston, said iluidbeing adapted to expand the packer by force of the piston, a removableweight run into the pipe on a cable to disengage the clutch, expand thepacker, and open the intake ports, a check valve in the shell below said tube, said check valvebeing adapted to be opened by pump fluid fromabove, an instrument case in the shell, and a drill bit upon the lowerend of the shell.

15. A combination well testing and cementing device including anoperating string of pipe, 2. shell surrounding the pipe and adapted tohave limited telescopic movement therewith, a packer mounted on saidshell, a tube attached to one member of the clutch and extendingdownward ytherefrom and having lateral openings for the pump uid, intakeports in said tube normally out of communication with similar ports insaid shell, the ports of the tube and shell being adapted to become incommunication with each other when the piston is forced downward, apiston on said the packer, and open the intake ports.

16. A well tool including a clutch coupling consisting of a male memberand two female members, each of said members having a plurality of keys,said female members being rotatable relative to each other when theclutch is disengaged and being locked together when the clutch isengaged, the keys upon the female members being adapted to be moved intoalignment With each other by one key longer than the others upon saidmale member.

17. A combination well testing and cementing device including anoperating string of pipe having within its lower portion a shellcontaining two racks and a pinion,one rack having an upward extensionformed into a head adapted to be engaged by a cable pulling means andhaving teeth engaged with mating teeth upon a pinion or gear securedwithin said. shell, the other of said racks having teeth engaged withmating teeth upon said gear, the latter teeth being formed upon aportion of smaller diameter than the portion having the teeth engagedwith the other rack, the second rack having a downward extension, anintake nipple attached to said extension, said nipple having lateralopenings for pump fluid, intake ports in said nipple normally out ofcommunication with similar ports in the shell surroundingthe nipple,said ports being adapted to become in communication with each other whenthe packer is expanded. a piston on said nipple or tube slidabie withinsaid shell, a chamber fullof iluid under said piston, said uid be- 19.In a device for cementing wells, an operating string of pipe extendingthrough a shell and adapted to lift the shell by means upon the lowerend of the pipe, a shell telescopically movable over said pipe andhaving lateral discharge openings, a packer on said shell, a pull tubeattached to said shell, this tube having lateral openings for entranceof liquid cement, discharge openings in the pipe proximate its lowerend, said openings being normally out of communication with thedischarge openings of the shell and adapted to become in communicationtherewith when the packer is expanded, and a. cable pulling meansadapted to engage a head upon the pull tube, whereby the packer may beexpanded and the discharge openings of the pipe and shell brought intocommunication with each other so that cement can bedischarged under pumppressure into the well below the packer.

ALEXANDER BOYNTON.

